CN111220522A - Core scale logging calculation method for hydrate saturation of high-argillaceous fine-grained sediment - Google Patents
Core scale logging calculation method for hydrate saturation of high-argillaceous fine-grained sediment Download PDFInfo
- Publication number
- CN111220522A CN111220522A CN201911028134.3A CN201911028134A CN111220522A CN 111220522 A CN111220522 A CN 111220522A CN 201911028134 A CN201911028134 A CN 201911028134A CN 111220522 A CN111220522 A CN 111220522A
- Authority
- CN
- China
- Prior art keywords
- porosity
- core
- magnetic resonance
- nuclear magnetic
- logging
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Pending
Links
Images
Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume, or surface-area of porous materials
- G01N15/08—Investigating permeability, pore-volume, or surface area of porous materials
- G01N15/088—Investigating volume, surface area, size or distribution of pores; Porosimetry
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N24/00—Investigating or analyzing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects
- G01N24/08—Investigating or analyzing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects by using nuclear magnetic resonance
- G01N24/081—Making measurements of geologic samples, e.g. measurements of moisture, pH, porosity, permeability, tortuosity or viscosity
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
- Y02A90/00—Technologies having an indirect contribution to adaptation to climate change
- Y02A90/30—Assessment of water resources
Abstract
The invention discloses a core scale logging calculation method for high argillaceous fine grain sediment hydrate saturation, which comprises the following steps of: drilling a natural gas hydrate sample, and carrying out pretreatment such as cutting, polishing, drying and the like on a rock core; measuring the length, diameter and density of the core in a dry state; measuring the porosity of the rock core by using a floating weight method after the rock core is saturated with water; putting the rock core completely saturated with water into a nuclear magnetic resonance instrument, and measuring the nuclear magnetic resonance porosity; crushing the rock core, and measuring the clay type and the respective absolute content of the rock core by using an X-ray diffractometer; establishing a relationship between the porosity difference and the absolute content of different clays; obtaining the true porosity of the stratum and the absolute contents of different clays according to conventional logging information; obtaining a nuclear magnetic resonance spectrum and nuclear magnetic resonance porosity according to the nuclear magnetic resonance logging data of the stratum; and obtaining the saturation of the natural gas hydrate according to the established natural gas hydrate logging calculation model. The method can accurately calculate the hydrate saturation of the high-argillaceous fine-grained sediment.
Description
Technical Field
The invention belongs to the field of energy exploration and development and geophysical logging, and particularly relates to a core scale logging calculation method for high argillaceous fine grain sediment hydrate saturation.
Background
The natural gas hydrate is used as clean energy and is the key point of future energy exploration and development. The method has the advantages that the enrichment zone of the natural gas hydrate is accurately identified, the hydrate saturation is quantitatively calculated, and the method has important significance for promoting efficient exploration and development of the natural gas hydrate. The logging technology can directly indicate and identify the hydrate enrichment zone by detecting the geophysical information of different detection ranges around the well. By combining the corresponding stratum model and the response equation, key information such as the porosity and the saturation of the natural gas hydrate can be obtained, and a basis is provided for the identification and development scheme formulation of the natural gas hydrate.
The natural gas hydrate has complex production shape, can be present in fine-grained loose sediments with high argillaceous content, and has great difference in logging response characteristics from conventional oil gas. The prior art directly continues to use a conventional oil gas logging evaluation method and thought, is difficult to accurately represent the enrichment and distribution rule of the hydrate, and cannot realize the quantitative calculation of the saturation of the hydrate.
The relaxation rate of the natural gas hydrate is high, and the low-field nuclear magnetic resonance logging instrument can not measure the information of the hydrate, so that the nuclear magnetic resonance porosity is lost. Therefore, according to the difference between the nuclear magnetic resonance logging porosity and other conventional logging (density, sound wave, neutron and the like) porosities, the natural gas hydrate saturation can be directly calibrated. However, when the sediment has high argillaceous content, fine particle size and low pore radius, the phenomenon of 'nuclear magnetic resonance porosity loss' also exists. If the logging result is not reasonably and effectively corrected, the calculated hydrate saturation is larger than the real hydrate saturation, and the reserves of the natural gas hydrates are difficult to accurately reflect.
Disclosure of Invention
Based on the technical problems, the invention provides a core scale logging calculation method for the hydrate saturation of the high-argillaceous fine-grained sediment.
The technical solution adopted by the invention is as follows:
a core scale logging calculation method for hydrate saturation of high-argillaceous fine-grained sediment comprises the following steps:
a, drilling a natural gas hydrate-containing high-argillaceous fine grain sediment core, and carrying out pretreatment such as cutting, polishing and drying on the core;
b, measuring basic parameters such as the length, the diameter, the density and the like of the rock core;
c, completely saturating the formation water with the core, taking out the core, and measuring the porosity by adopting a float-weight method to obtain the porosity value of the core by adopting the float-weight method;
d, putting the rock core of the fully saturated formation water into a nuclear magnetic resonance instrument, and measuring nuclear magnetic resonance porosity to obtain a nuclear magnetic resonance porosity value of the rock core;
e, taking out the rock core, crushing, putting into an X-ray diffractometer, and measuring the absolute content of the clay minerals such as kaolinite, montmorillonite, illite, chlorite and the like;
f, subtracting the nuclear magnetic resonance porosity value from the float-weight porosity value of the rock core to obtain a porosity difference value phidiff；
g, establishing a relation between the porosity difference value and the absolute content of the kaolinite, the montmorillonite, the illite, the chlorite and other clay minerals by adopting a multiple regression method, wherein the relation is as shown in the following formula (1):
φdiff＝φf-φNMR＝a×VK+b×VM+c×VI+d×Vc+e (1)
in the formula: phi is adiffIs porosityA difference value; phi is afThe porosity value is a float-weight method porosity value and represents the real porosity of the rock core; phi is aNMRIs the core nmr porosity value, representing porosity affected by shale; vK，VM，VIAnd VcRespectively represent the absolute contents of kaolinite, montmorillonite, illite and chlorite; a. b, c, d and e are fitting parameters respectively;
h, acquiring the natural gamma energy spectrum, density, neutron, sound wave and resistivity conventional logging information of the stratum where the core is positioned, and obtaining the logging porosity value phi of the underground stratum by applying an optimized inversion methodOPTAnd the absolute content of clay minerals such as kaolinite, montmorillonite, illite, chlorite and the like, and calculating by using the formula (1) to obtain a porosity difference value phi of the underground stratumdiffL；
i obtaining nuclear magnetic resonance logging data of a stratum where the rock core is located, and performing non-negative least square inversion on the nuclear magnetic resonance logging data to obtain a nuclear magnetic resonance spectrum and a nuclear magnetic resonance logging porosity value phiNMRL；
j, establishing a logging calculation model of the natural gas hydrate, which is as the following formula (2):
in the formula SHIs the hydrate saturation value;
and (4) calculating according to the formula (2) to obtain the natural gas hydrate saturation value.
The larmor frequency of the nmr is preferably 2 mhz, although other frequencies are also suitable.
The above porosity difference value phidiffGreater than 0.
Preferably, the diameter of the core is 2.54 cm, and the length of the core is distributed between 3 cm and 5 cm. Of course, other dimensions are also suitable.
The beneficial technical effects of the invention are as follows:
the invention provides a core scale logging calculation method for high argillaceous fine grain sediment hydrate saturation, which can correct the influence of the type and content of clay in the high argillaceous fine grain sediment on nuclear magnetic resonance porosity, effectively improve the calculation precision of the hydrate saturation and provide reference for logging evaluation and exploration and development scheme formulation of a natural gas hydrate.
Drawings
The invention will be further described with reference to the following detailed description and drawings:
FIG. 1 is a flow chart of a core scale logging calculation method for hydrate saturation of high argillaceous fine grain sediments provided by the present invention;
FIG. 2 is a plot of the float weight porosity and NMR porosity of a core in an example of the invention;
FIG. 3 is a graph of the porosity difference of the core as a function of the absolute content of kaolinite in an example of the invention;
FIG. 4 is a graph of the porosity difference of the core versus the absolute content of illite in an example of the present disclosure;
FIG. 5 is a graph of the relationship between the porosity difference value of the core and the absolute content of chlorite in an embodiment of the invention;
FIG. 6 is a graph showing a relationship between a porosity difference value of a core and an absolute content of montmorillonite in an example of the present invention;
FIG. 7 is a graph comparing the measured porosity difference of the core with the porosity difference calculated using equation (1) in an embodiment of the present disclosure;
fig. 8 is a graph comparing the measured natural gas hydrate saturation of the core with the natural gas hydrate saturation calculated using equation (2) in an example of the present invention.
Detailed Description
The invention provides a core scale logging calculation method for hydrate saturation of high-argillaceous fine-grained sediment, which is a calculation method for analyzing the relation between the porosity difference value and the absolute contents of different types of clay by measuring and analyzing the buoyant gravity porosity, the nuclear magnetic resonance porosity and the clay type and the respective absolute contents of the clay type and the core in a completely water-containing state through a laboratory, obtaining the porosity difference value through multiple regression, respectively obtaining the true porosity and the nuclear magnetic resonance logging porosity of an underground stratum under logging conditions, further establishing a logging calculation model for the hydrate saturation, and has important significance for hydrate logging identification, reservoir evaluation and the like.
A core scale logging calculation method for hydrate saturation of high-argillaceous fine-grained sediment specifically comprises the following steps:
drilling a natural gas hydrate deposit, and carrying out pretreatment such as cutting, polishing, drying and the like on a rock core;
b, measuring basic parameters such as the length, the diameter, the density and the like of the rock core;
c, completely saturating the formation water with the rock core, taking out the rock core, and measuring the porosity by adopting a float-weight method;
d, putting the completely saturated rock core into a nuclear magnetic resonance instrument, and measuring the nuclear magnetic resonance porosity;
e, taking out the rock core, crushing, putting into an X-ray diffractometer, and measuring the absolute content of the clay minerals such as kaolinite, montmorillonite, illite, chlorite and the like;
f, subtracting the nuclear magnetic resonance porosity from the float-weight porosity of the rock core to obtain a porosity difference value phidiff；
g, establishing a relation between the porosity difference value and the absolute contents of the kaolinite, the montmorillonite, the illite, the chlorite and other clay minerals by adopting a multiple regression method, wherein the relation is as follows:
φdiff＝φf-φNMR＝a×VK+b×VM+c×VI+d×Vc+e (1)
in the formula: phi is adiffIs a porosity difference value; phi is afThe porosity of the core is represented by the true porosity of the core; phi is aNMRIs the core nmr porosity, representing porosity affected by mudiness; vK，VM，VIAnd VcRespectively represent the absolute contents of kaolinite, montmorillonite, illite and chlorite; a. b, c, d and e are fitting parameters, respectively.
g, acquiring natural gamma energy spectrum, density, neutron, sound wave and resistivity conventional logging information of the stratum where the core is located, and obtaining the logging porosity phi of the underground stratum by applying an optimized inversion methodOPTAnd kaolinite, montmorillonite, illite, chlorite and other clay mineralsThe absolute content of the substances, and the porosity difference value phi of the underground stratum is calculated by using the formula (1)diffL；
h, acquiring nuclear magnetic resonance logging data of the stratum where the rock core is located, and performing non-negative least square inversion on the nuclear magnetic resonance logging data to obtain a nuclear magnetic resonance spectrum and nuclear magnetic resonance logging porosity phiNMRL；
i, establishing a logging calculation model of the natural gas hydrate, as follows:
adopting a formula (2) and substituting the porosity value phi of the well logging obtained in the step g and the step hOPTPorosity difference value phidiffLAnd nuclear magnetic resonance logging porosity value phiNMRLAnd calculating to obtain the saturation value of the natural gas hydrate.
The invention is further described below with reference to the accompanying drawings.
A core scale logging calculation method for high argillaceous fine grain sediment hydrate saturation fully considers the influence of clay type and content on nuclear magnetic resonance logging response, and a fitting formula of porosity difference values is established by analyzing the relation between the porosity difference values and the clay content in a laboratory. And then obtaining the contents of different clay minerals in the stratum by adopting an optimized logging interpretation method, effectively correcting a natural gas hydrate saturation calculation model, and finally realizing logging evaluation of the natural gas hydrate saturation.
FIG. 1 is a flow chart of a core scale logging calculation method for hydrate saturation of high argillaceous fine-grained sediment, which mainly comprises the following steps: (1) drilling a natural gas hydrate sample, and carrying out pretreatment such as cutting, polishing, drying and the like on a rock core; (2) measuring the length, diameter and density of the core in a dry state; (3) measuring the porosity of the rock core by using a floating weight method after the rock core is saturated with water; (4) putting the rock core completely saturated with water into a nuclear magnetic resonance instrument, and measuring the nuclear magnetic resonance porosity; (5) crushing the rock core, and measuring the clay type and the respective absolute content of the rock core by using an X-ray diffractometer; (6) establishing a relationship between the porosity difference and the absolute content of different clays according to formula (1); (7) obtaining conventional logging information of a stratum, and obtaining the real porosity of the stratum and the absolute contents of different clays by applying optimized inversion; (8) acquiring nuclear magnetic resonance logging data of a stratum, and obtaining a nuclear magnetic resonance spectrum and nuclear magnetic resonance porosity by applying non-negative least square inversion; (9) obtaining a porosity difference value of the actual stratum according to the fitting parameters of the formula (1), and obtaining the saturation of the natural gas hydrate according to the formula (2); the nine parts are not available and the order may not be reversed.
FIG. 2 is a graph of the relationship between the float weight porosity and the NMR porosity of a core in an example of the invention. It can be seen from the figure that the nuclear magnetic resonance porosity of the core is generally smaller than the float-weight porosity under the influence of the shale, and if the difference between the nuclear magnetic resonance porosity and the float-weight porosity is directly regarded as the natural gas hydrate saturation, the nuclear magnetic resonance porosity and the float-weight porosity are not in accordance with the actual situation.
Fig. 3 is a graph of the relationship between the porosity difference value of the core and the absolute content of kaolinite in the example of the invention. As can be seen from the graph, the porosity difference value of the core is proportional to the absolute content of kaolinite.
Fig. 4 is a graph of the porosity difference value of the core and the absolute content of illite in the example of the present invention. As can be seen from the figure, the porosity difference value of the core is proportional to the absolute content of illite.
Fig. 5 is a graph of the relationship between the porosity difference value of the core and the absolute content of chlorite in the example of the invention. As can be seen from the figure, the porosity difference value of the core is proportional to the absolute content of chlorite.
Fig. 6 is a graph showing a relationship between a porosity difference value of a core and an absolute content of montmorillonite in an example of the present invention. As can be seen from the figure, the value of the difference in porosity of the core is directly proportional to the absolute content of montmorillonite.
Fig. 7 is a comparison graph of the measured porosity difference value of the core and the porosity difference value calculated by using the formula (1) in the embodiment of the present invention. As can be seen from the figure, the calculated porosity difference value substantially matches the measured porosity difference value.
Fig. 8 is a graph comparing the measured natural gas hydrate saturation of the core with the natural gas hydrate saturation calculated using equation (2) in an example of the present invention. As can be seen from the figure, the calculated saturation of the natural gas hydrate substantially coincides with the measured value.
Claims (1)
1. A core scale logging calculation method for hydrate saturation of high-argillaceous fine-grained sediment is characterized by comprising the following steps:
a, drilling a natural gas hydrate-containing high-argillaceous fine grain sediment core, and carrying out cutting, polishing and drying pretreatment on the core;
b, measuring basic parameters of the core, including the length, the diameter and the density of the core;
c, completely saturating the formation water with the core, taking out the core, and measuring the porosity by adopting a float-weight method to obtain the porosity value of the core by adopting the float-weight method;
d, placing the completely saturated rock core into a nuclear magnetic resonance instrument, and measuring nuclear magnetic resonance porosity to obtain a nuclear magnetic resonance porosity value of the rock core;
e, taking out the rock core, crushing, putting into an X-ray diffractometer, and measuring the absolute content of kaolinite, montmorillonite, illite and chlorite clay minerals;
f, subtracting the nuclear magnetic resonance porosity value from the float-weight porosity value of the rock core to obtain a porosity difference value phidiff；
g, establishing a relation between the porosity difference value and the absolute contents of kaolinite, montmorillonite, illite and chlorite clay minerals by adopting a multiple regression method, wherein the relation is as shown in the following formula (1):
φdiff＝φf-φNMR＝a×VK+b×VM+c×VI+d×Vc+e (1)
in the formula: phi is adiffIs a porosity difference value; phi is afThe porosity value is a float-weight method porosity value and represents the real porosity of the rock core; phi is aNMRIs the core nmr porosity value, representing porosity affected by shale; vK，VM，VIAnd VcRespectively represent the absolute contents of kaolinite, montmorillonite, illite and chlorite; a. b, c, d and e are fitting parameters respectively;
h, acquiring the natural gamma-ray energy spectrum, density, neutron, sound wave and resistivity conventional logging information of the stratum where the rock core is positionedObtaining a well-logging porosity value phi of the underground stratum by applying an optimized inversion methodOPTAnd the absolute content of kaolinite, montmorillonite, illite and chlorite clay minerals, and calculating by using the formula (1) to obtain the porosity difference value phi of the underground stratumdiffL；
i obtaining nuclear magnetic resonance logging data of a stratum where the rock core is located, and performing non-negative least square inversion on the nuclear magnetic resonance logging data to obtain a nuclear magnetic resonance spectrum and a nuclear magnetic resonance logging porosity value phiNMRL；
j, establishing a logging calculation model of the natural gas hydrate, which is as the following formula (2):
in the formula SHIs the hydrate saturation value;
and (4) calculating according to the formula (2) to obtain a hydrate saturation value.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201911028134.3A CN111220522A (en) | 2019-10-28 | 2019-10-28 | Core scale logging calculation method for hydrate saturation of high-argillaceous fine-grained sediment |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201911028134.3A CN111220522A (en) | 2019-10-28 | 2019-10-28 | Core scale logging calculation method for hydrate saturation of high-argillaceous fine-grained sediment |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN111220522A true CN111220522A (en) | 2020-06-02 |
Family
ID=70805814
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201911028134.3A Pending CN111220522A (en) | 2019-10-28 | 2019-10-28 | Core scale logging calculation method for hydrate saturation of high-argillaceous fine-grained sediment |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN111220522A (en) |
Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN112149282A (en) * | 2020-08-28 | 2020-12-29 | 中国石油天然气集团有限公司 | Physical calculation method and system for natural gas hydrate saturation rock in well |
| CN112182839A (en) * | 2020-08-28 | 2021-01-05 | 中国石油天然气集团有限公司 | Modeling method and device for determining hydrate reservoir velocity dispersion and/or attenuation |
| CN112485281A (en) * | 2020-10-19 | 2021-03-12 | 中国地质大学（北京） | Method for dynamically measuring gas hydrate saturation and permeability in porous medium |
| CN113189674A (en) * | 2021-05-07 | 2021-07-30 | 中国石油大学(北京) | Method and system for estimating saturation of natural gas hydrate |
| CN113189674B (en) * | 2021-05-07 | 2024-04-23 | 中国石油大学(北京) | Saturation estimation method and system for natural gas hydrate |
Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US20080195320A1 (en) * | 2004-09-14 | 2008-08-14 | The Trustees Of Columbia University In The City Of New York | Systems And Methods For Determining In-Situ Gas Hydrate Saturation |
| CN105240001A (en) * | 2015-09-23 | 2016-01-13 | 中国石油大学(北京) | Method and device for correcting nuclear magnetic resonance logging porosity |
| CN105370272A (en) * | 2015-12-07 | 2016-03-02 | 中国石油集团川庆钻探工程有限公司地球物理勘探公司 | Shale gas reservoir logging evaluate method |
| CN106066492A (en) * | 2016-06-06 | 2016-11-02 | 中国石油大学(华东) | A kind of bearing calibration of nuclear magnetic resonance log porosity echo sounding impact |
| CN106383365A (en) * | 2016-10-28 | 2017-02-08 | 中国地质大学（北京） | Method for correcting nuclear magnetic resonance porosity of igneous rock by means of plate |
| CN106443800A (en) * | 2016-07-18 | 2017-02-22 | 中国石油天然气集团公司 | Nuclear magnetism porosity correction method of intermediate-basic volcanic rocks |
| CN107861160A (en) * | 2017-11-03 | 2018-03-30 | 中国石油大学(华东) | The emulation of the impedance measurement device of porous media containing gas hydrates and analysis method |
-
2019
- 2019-10-28 CN CN201911028134.3A patent/CN111220522A/en active Pending
Patent Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US20080195320A1 (en) * | 2004-09-14 | 2008-08-14 | The Trustees Of Columbia University In The City Of New York | Systems And Methods For Determining In-Situ Gas Hydrate Saturation |
| CN105240001A (en) * | 2015-09-23 | 2016-01-13 | 中国石油大学(北京) | Method and device for correcting nuclear magnetic resonance logging porosity |
| CN105370272A (en) * | 2015-12-07 | 2016-03-02 | 中国石油集团川庆钻探工程有限公司地球物理勘探公司 | Shale gas reservoir logging evaluate method |
| CN106066492A (en) * | 2016-06-06 | 2016-11-02 | 中国石油大学(华东) | A kind of bearing calibration of nuclear magnetic resonance log porosity echo sounding impact |
| CN106443800A (en) * | 2016-07-18 | 2017-02-22 | 中国石油天然气集团公司 | Nuclear magnetism porosity correction method of intermediate-basic volcanic rocks |
| CN106383365A (en) * | 2016-10-28 | 2017-02-08 | 中国地质大学（北京） | Method for correcting nuclear magnetic resonance porosity of igneous rock by means of plate |
| CN107861160A (en) * | 2017-11-03 | 2018-03-30 | 中国石油大学(华东) | The emulation of the impedance measurement device of porous media containing gas hydrates and analysis method |
Non-Patent Citations (3)
| Title |
|---|
| 侯颉: "青海省三露天天然气水合物储层测井解释方法研究", 《中国优秀硕士学位论文全文数据库 基础科学辑》 * |
| 李晓峰 等: "中基性火山岩顺磁物质对核磁共振孔隙度的影响分析", 《测井技术》 * |
| 范宜仁 等: "天然气水合物储层测井响应与评价方法综述", 《测井技术》 * |
Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN112149282A (en) * | 2020-08-28 | 2020-12-29 | 中国石油天然气集团有限公司 | Physical calculation method and system for natural gas hydrate saturation rock in well |
| CN112182839A (en) * | 2020-08-28 | 2021-01-05 | 中国石油天然气集团有限公司 | Modeling method and device for determining hydrate reservoir velocity dispersion and/or attenuation |
| CN112485281A (en) * | 2020-10-19 | 2021-03-12 | 中国地质大学（北京） | Method for dynamically measuring gas hydrate saturation and permeability in porous medium |
| CN113189674A (en) * | 2021-05-07 | 2021-07-30 | 中国石油大学(北京) | Method and system for estimating saturation of natural gas hydrate |
| CN113189674B (en) * | 2021-05-07 | 2024-04-23 | 中国石油大学(北京) | Saturation estimation method and system for natural gas hydrate |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| RU2146380C1 (en) | Determination of petrophysical properties of geological structure by means of nuclear magnetic resonance | |
| WO2017024700A1 (en) | Device for calculating content of organic carbon in source rock | |
| US10996364B2 (en) | System and method for determining water-filled porosity and water salinity in well cores and logs | |
| US11435304B2 (en) | Estimating downhole fluid volumes using multi-dimensional nuclear magnetic resonance measurements | |
| US10451763B2 (en) | Evaluation of formation utilizing wideband electromagnetic measurements | |
| CN106908856B (en) | A kind of earthquake prediction method of lacustrine facies thin layer dolostone reservoirs | |
| CN111220522A (en) | Core scale logging calculation method for hydrate saturation of high-argillaceous fine-grained sediment | |
| Kendall et al. | Seismic anisotropy as an indicator of reservoir quality in siliciclastic rocks | |
| CN107688037A (en) | It is a kind of that the method for determining Rock in Well grading curve is distributed using nuclear magnetic resonance log T2 | |
| US9791584B2 (en) | Determining petrophysical properties using sodium nuclear magnetic resonance (NMR) logs | |
| CN110344822B (en) | Determination method of water saturation of calcareous compact reservoir | |
| CN113775326B (en) | Method and device for evaluating movable water saturation, electronic equipment and medium | |
| Newsham et al. | Tutorial: Organic-Mudstone Petrophysics: Workflow to Estimate Storage Capacity | |
| CN110658555A (en) | Reservoir fluid factor construction method and reservoir fluid identification method | |
| Evans et al. | A geological approach to permeability prediction in clastic reservoirs | |
| Deng et al. | A new index used to characterize the near-wellbore fracture network in naturally fractured gas reservoirs | |
| Zahaf et al. | Vertical permeability from in situ horizontal measurements in shaly-sand reservoirs | |
| CN116027453A (en) | Quantitative evaluation method and device for saturation of hydrate mixed layer | |
| CN115901563A (en) | Method for calculating permeability of low-porosity and low-permeability reservoir by combining nuclear magnetic resonance and resistivity | |
| Feng et al. | TOC estimation of shale oil reservoir by combining nuclear magnetic resonance logging and nuclear physics logging | |
| CN113720745A (en) | Method for calculating porosity of reservoir stratum containing carbon debris by geophysical logging | |
| Li et al. | Application of nuclear magnetic resonance logging in the low-resistivity reservoir—Taking the XP area as an example | |
| CN114086938B (en) | Method for predicting gas saturation of heterogeneous sandstone reservoir | |
| CN112268919B (en) | Method for identifying tight sandstone reservoir fluid by nuclear magnetic resonance inversion | |
| Awuyo et al. | Achieving Best Practices in Log Pre-Processing for Facies and Permeability Modeling |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| RJ01 | Rejection of invention patent application after publication |
Application publication date: 20200602 |
|
| RJ01 | Rejection of invention patent application after publication |